Riviera Resources Reports Third-Quarter 2019 Results and Announces Sale of East Texas Overton Properties for $18.5 Million

November 07, 2019 06:50 ET | Source: Riviera Resources, Inc.

HOUSTON, Nov. 07, 2019 (GLOBE NEWSWIRE) — Riviera Resources, Inc. (OTCQX: RVRA) (“Riviera” or the “Company”) and its wholly owned subsidiary, Blue Mountain Midstream LLC (“Blue Mountain”) announces financial and operating results for the third quarter 2019.

The Company highlights the following accomplishments:

Increased previously announced $100 million share repurchase authorization to a total of $150 million
Returned over $140 million of capital to shareholders through share repurchases and tender offer since the beginning of the year, and over $295 million since August 2018
Signed definitive agreements to sell our remaining Hugoton Basin assets for a contract price of $295 million, and interests in properties located in the Overton field of East Texas for a contract price of $18.5 million
Ended the third quarter with a consolidated cash balance of ~$83 million and ~$61 million drawn on the Blue Mountain Credit Facility
Averaged approximately 242 MMcfe/d of production in the third quarter, in line with our guidance range
Invested Upstream capital of approximately $6 million, ~33% below the guidance target for the quarter

Blue Mountain highlights:

Entered into a long-term, fee-based crude oil gathering agreement with Roan Resources, Inc. (“Roan”) and construction commenced on initial facilities for the North and South systems
Roan entered into an agreement and plan of merger with Citizen Energy Operating, LLC (“Citizen”), which is a portfolio company of Warburg Pincus
Placed into service water gathering pipelines, connecting to 14 Roan pads
Closed the acquisition of Lumen Midstream Partnership, LLC, and constructed interconnect facilities, with volumes redirected to the cryo plant beginning on October 1, 2019
Continued engagement with Tudor, Pickering, Holt & Co. to review strategic alternatives to unlock unrealized value

David Rottino, Riviera’s President and Chief Executive Officer, commented, “I am very pleased with Riviera’s performance in the third quarter. We remain relentlessly focused on our commitment to maximizing shareholder value through our strategy of capital discipline, returning capital to shareholders and efficiently managing our assets. So far this year, we have generated approximately $220 million in proceeds through opportunistic asset monetizations, and returned over $140 million of capital to shareholders through our ongoing share repurchase program and July tender offer. In addition, we will generate significant proceeds from the sale of our remaining Hugoton assets that we still expect to close in the fourth quarter of this year that can be used to return capital to shareholders. Finally, we continue to work with Tudor, Pickering, Holt & Co. to review strategic alternatives for our Blue Mountain midstream business.”


Key Financial Results ⁽¹⁾
	Three Months Ended		Nine Months Ended
	September 30,		September 30,
$ in millions	2019	2018	2019	2018
Average daily production (MMcfe/d)	242	302	264	338
Total oil, natural gas and NGL revenues	$ 51	$ 90	$ 194	$ 314
(Loss) income from continuing operations	$ (226)	($ 33)	$ (220)	$ 10
(Loss) income from discontinued operations, net of income taxes	$ -	($ 15)	$ -	$ 20
Net (loss) income	$ (226)	($ 48)	$ (220)	$ 30
Adjusted EBITDAX (a non-GAAP financial measure) ⁽²⁾	$ 21	$ 12	$ 84	$ 63
Net cash provided by (used in) operating activities	$ 29	($ 85)	$ 88	$ (28)
Oil and natural gas capital	$ 6	$ 7	$ 60	$ 24
Total capital ⁽³⁾	$ 42	$ 34	$ 144	$ 143

(1) All amounts reflect continuing operations with the exception of net (loss) income for the three months and nine months ended September 30, 2018.
(2) Includes severance costs of approximately $2 million and success fee on capital reimbursement agreement of approximately $2 million for both the three months and nine months ended September 30, 2019, and severance costs of approximately $8 million and $26 million for the three months and nine months ended September 30, 2018, respectively.
(3) Includes approximately $3 million of capital for the Lumen acquisition for both the three months and nine months ended September 30, 2019.

Opportunistic Asset Monetizations
Thus far in 2019, the Company has closed six transactions that in combination generated proceeds of approximately $220 million. The six transactions include the sale of the Arkoma Basin assets (closed January 2019), the monetization of a portion of the Company’s helium reserves in the Hugoton Basin utilizing a VPP structure (closed March 2019), the sale of certain non-operated properties located in the Hugoton Basin (closed May 2019), the sale of properties located in Michigan (closed July 2019), the sale of certain non-core properties located in North Louisiana (closed August 2019), and the sale of properties located in Illinois (closed September 2019).

The Company has also signed definitive agreements to sell its remaining interests in properties located in the Hugoton Basin, expected to close in the fourth quarter of 2019, and its interest in properties located in the Overton field in East Texas, that is expected to close in the first quarter of 2020. In combination, the transactions are expected to generate estimated proceeds of approximately $300 million. The Board and management will determine the use of proceeds, which consistent with past history may include a significant return of capital to shareholders.

Continuation of Share Repurchase Plan
The Company has returned over $140 million of capital to shareholders through a tender offer and share repurchases since the beginning of the year, and over $295 million since August 2018.

On July 18, 2019, the Board increased the share repurchase authorization to $150 million of the Company’s outstanding shares of common stock. Through September 30, 2019, the Company repurchased an aggregate of 8,916,526 shares at an average price of $13.55 for a total cost of approximately $121 million. In the third quarter alone the Company bought back 2,327,416 shares at an average price of $10.70 for a total cost of approximately $25 million. As of October 31, 2019, approximately $28 million was available for share repurchase under the program.

Third Quarter 2019 Activity – Upstream Assets
The Company performed in line with expectations in the third quarter with respect to its upstream assets. Production for the third quarter averaged approximately 242 MMcfe/d, in line with our guidance range. Upstream capital expenditures were approximately $6 million, 33% below the guidance target for the quarter. Adjusted G&A expenses were approximately $9 million, and operating expenses were approximately $39 million, both in-line with guidance ranges for the quarter.

Blue Mountain Business Update
In the third quarter of 2019, natural gas throughput averaged 114 MMcf/d and NGLs produced were 7,250 bpd. Average natural gas throughput for the nine months ending September 30, 2019 was 117 MMcf/d. During the third quarter, 13 wells were turned to sales on the Blue Mountain system; however, throughput volumes were impacted due to our primary customer Roan preloading or temporarily shutting-in 15 producing wells during the quarter, contributing to an average throughput loss on the system of ~11 MMcf/d since the second quarter of 2019. We anticipate these wells and volumes to return in the fourth quarter of 2019 and the first quarter of 2020.

Management expects throughput volumes from its primary customer to remain relatively flat during the remainder of 2019 as Roan recently entered into an agreement and plan of merger with Citizen. Roan has significantly curtailed operations pending the closing of that transaction, which is anticipated to take place prior to yearend. Citizen is a portfolio company of Warburg Pincus, which has over $62 billion of assets under management and substantial experience in the energy sector.

On August 5, 2019, Blue Mountain acquired 100% interests in Lumen Midstream Partnership, LLC, including approximately 55 miles of natural gas gathering pipelines and an 18 MMcf/d processing plant. During the quarter, the Lumen system was connected to the Blue Mountain system, adding natural gas throughput of ~5 MMcf/d at the cryo plant, beginning on October 1, 2019.

Blue Mountain began gathering produced water on pipelines for Roan in July 2019, averaging 8,280 bpd during the third quarter of 2019. As the company progresses on the buildout of its water gathering system, it continues to transport produced water via third-party trucking services, hauling 5 million barrels of water in total, or averaging 54,165 bpd, during the third quarter of 2019. In September 2019, Blue Mountain executed a new water services agreement with a large independent producer. The agreement includes a minimum volume commitment of 5,000 bpd over a three-year term, with facilities estimated in-service in November 2019. In addition, Blue Mountain has placed in-service its first owned and operated disposal well and is constructing two more water disposal facilities, one of which is estimated to be in-service in the fourth quarter of 2019. Furthermore, Blue Mountain has acquired additional disposal capacity through a non-operated interest in another well that went in service in October 2019.

Blue Mountain entered into a crude oil gathering agreement with Roan Resources in July 2019. Construction has commenced on the initial facilities consisting of approximately 50 miles of gathering pipelines across the North and South systems, with an estimated in-service date in the first half of 2020.

During the quarter, the business was impacted by lower throughput volumes and overall lower commodity prices. Also, the business continued to be impacted by the NGL pricing differentials at Conway and Mont Belvieu, along with ineffective hedges related to these pricing differences. As a result, Blue Mountain’s third quarter adjusted EBITDA decreased by approximately $5 million compared with second quarter results. The elimination of the impact of the hedges would have added approximately $3 million to Blue Mountain’s Adjusted EBITDA. Management expects to eliminate all basis dislocation in the first quarter of 2020 when ONEOK’s Arbuckle II Pipeline is completed.

Capital expenditures for the third quarter were approximately $36 million (including approximately $3 million of acquisition capital), with the majority of capital being invested in the construction of water gathering pipelines.

Balance Sheet and Liquidity
Riviera and Blue Mountain have established separate credit facilities. As of September 30, 2019, there were no borrowings outstanding on Riviera’s revolving credit facility, and borrowing commitments of up to $90 million with available borrowing capacity of approximately $57 million, inclusive of outstanding letters of credit. At quarter end, Riviera had approximately $62 million of cash. In September 2019, Riviera amended its Credit Facility. The amendment resulted in a borrowing commitment reduction from $230 million to $90 million, primarily due to pending asset sales, including the sale of remaining Hugoton Basin properties expected to close in the fourth quarter of 2019. In addition to extending the facility’s term by one year, Riviera reduced its pricing grid by 50 basis points.

As of September 30, 2019, Blue Mountain had approximately $61 million drawn on its revolving credit facility, and borrowing commitments of up to $200 million with available borrowing capacity of approximately $126 million, including outstanding letters of credit, subject to covenant restrictions in the Blue Mountain Credit Facility, and approximately $21 million ending cash balance.

As of September 30, 2019 the Company had a consolidated ending cash balance of approximately $83 million. With $61 million drawn on Blue Mountain’s credit facility, the company had approximately $22 million in net cash.


Third Quarter Actuals
Below is a summary of the Company’s consolidated third quarter results.

	Q3 2019 Actuals	Q3 2019 Actuals	Q3 2019 Actuals
	Upstream	Blue Mountain	Consolidated

Net Production (MMcfe/d)	242		242
Natural gas (MMcf/d)	194		194
Oil (Bbls/d)	2,085		2,085
NGL (Bbls/d)	5,979		5,979

Other revenues, net (in thousands)⁽¹⁾	$ 8,679 ⁽²⁾	$ 6,426 ⁽³⁾	$ 15,105 ⁽⁴⁾
Helium revenues	$ 5,120 ⁽⁵⁾		$ 5,120 ⁽⁵⁾
Jayhawk / Other	$ 3,559		$ 3,559
Blue Mountain		$ 6,426 ⁽³⁾	$ 6,426 ⁽³⁾

Costs (in thousands)	$ 39,050	$ 643	$ 39,693
Lease operating expenses	$ 18,307		$ 18,307
Transportation expenses	$ 16,275		$ 16,275
Taxes, other than income taxes	$ 4,468	$ 643	$ 5,111

Adjusted general and administrative expenses (Non-GAAP) ⁽⁶⁾	$ 8,612 ⁽⁷⁾	$ 3,317 ⁽⁸⁾	$ 11,929 ⁽⁹⁾
General and administrative- severance expenses	$ 2,246		$ 2,246

(in thousands)
Adjusted EBITDAX (Non-GAAP)	$ 19,464	$ 1,219 ⁽¹⁰⁾	$ 20,683 ⁽¹⁰⁾
Cash interest expense (Non-GAAP) ⁽¹¹⁾	$ 1,008	$ 492	$ 1,500
Oil and natural gas capital	$ 5,803		$ 5,803
Total capital	$ 5,904	$ 36,590	$ 42,494

(1) Includes other revenues and margin on marketing activities
(2) Includes other revenues of approximately $5.5 million, plus marketing revenues of approximately $11.1 million, less marketing expenses of approximately $7.9 million
(3) Includes marketing revenues of approximately $34.7 million, less adjusted marketing expenses of approximately $28.3 million. Adjusted marketing expenses is a non-GAAP measure that excludes share-based compensation expenses of less than $0.1 million, and losses on derivatives of approximately $1.4 million
(4) Includes other revenues of approximately $5.5 million, plus marketing revenues of approximately $45.8 million, less adjusted marketing expenses of approximately $36.2 million. Adjusted marketing expenses is a non-GAAP measure that excludes share-based compensation expenses of less than $0.1 million, and losses on derivatives of approximately $1.4 million
(5) Includes helium revenues from the VPP Interests of approximately $3.7 million
(6) Adjusted general and administrative expenses is a non-GAAP measure that excludes share-based compensation expenses and severance expenses presented for the purpose of comparing to guidance
(7) Represents general and administrative expenses of approximately $11.4 million, excluding share-based compensation expenses of approximately $0.6 million, and severance expenses of approximately $2.2 million
(8) Represents general and administrative expenses of approximately $5.5 million, excluding share-based compensation expenses of approximately $2.2 million
(9) Represents general and administrative expenses of approximately $16.9 million, excluding share-based compensation expenses of approximately $2.8 million, and severance expenses of approximately $2.2 million
(10) Includes success fee on capital reimbursement agreement for partial sale of NW STACK gathering infrastructure to producer of approximately $1.7 million
(11) Excludes non cash amortization

Upstream Segment – Third Quarter Actuals versus Guidance
The comparison to guidance below is for the upstream assets only. The Company did not provide third quarter 2019 guidance for Blue Mountain.

	Q3 2019 Actuals	Q3 2019 Guidance

Net Production (MMcfe/d)	242	233 – 255
Natural gas (MMcf/d)	194	185 – 205
Oil (Bbls/d)	2,085	1,900 – 2,100
NGL (Bbls/d)	5,979	6,000 – 6,300

Other revenues, net (in thousands)⁽¹⁾	$ 8,679 ⁽²⁾	$ 7,000 – $ 9,000
Helium revenues	$ 5,120 ⁽³⁾	$ 4,500 – $ 5,500 ⁽³⁾
Jayhawk / Other	$ 3,559	$ 2,500 – $ 3,500

Costs (in thousands)	$ 39,050	$ 36,500 – $ 41,500
Lease operating expenses	$ 18,307	$ 17,000 – $ 19,000
Transportation expenses	$ 16,275	$ 16,000 – $ 17,000
Taxes, other than income taxes	$ 4,468	$ 3,500 – $ 5,500

Adjusted general and administrative expenses (Non-GAAP) ⁽⁴⁾	$ 8,612 ⁽⁵⁾	$ 8,500 – $ 9,500
General and administrative- severance expenses	$ 2,246	$ 1,500 – $ 2,000

Targets (Mid-Point) (in thousands)
Adjusted EBITDAX (Non-GAAP)	$ 19,464	$ 19,000
Capital expenditures	$ 5,904	$ 9,000
VPP Notes interest expense payments ⁽⁶⁾	$ 1,011	$ 1,000
VPP Notes principal payments	$ 2,666	$ 2,700

(1) Includes other revenues and margin on marketing activities
(2) Includes other revenues of approximately $5.5 million, plus marketing revenues of approximately $11.1 million, less marketing expenses of approximately $7.9 million
(3) Includes helium revenues from the VPP Interests of approximately $3.7 million
(4) Adjusted general and administrative expenses is a non-GAAP measure that excludes share-based compensation expenses and severance expenses presented for the purpose of comparing to guidance
(5) For the three months ended September 30, 2019 represents general and administrative expenses of approximately $11.4 million, excluding share-based compensation expenses of approximately $0.6 million, and severance expenses of approximately $2.2 million
(6) Excludes non cash amortization

Upstream Segment – Fourth Quarter and Full Year 2019 Guidance
The guidance below is for the Upstream assets only. Guidance estimates have been adjusted for the sale of remaining properties located in Hugoton expected to close in the fourth quarter of 2019.


	Q4 2019E	FY 2019E
Net Production (MMcfe/d)	162 – 180	238 – 243
Natural gas (MMcf/d)	133 – 147	194 – 198
Oil (Bbls/d)	1,400 – 1,600	1,655 – 1,705
NGL (Bbls/d)	3,500 – 3,900	5,650 – 5,750

Other revenues, net (in thousands)⁽¹⁾	$ 3,000 – $ 5,000	$ 31,000 – $ 33,000
Helium revenues	$ 1,000 – $ 2,000 ⁽²⁾	$ 16,500 – $ 17,500 ⁽³⁾
Jayhawk / Other	$ 2,000 – $ 3,000	$ 14,500 – $ 15,500

Costs (in thousands)	$ 25,500 – $ 29,500	$ 157,500 – $ 161,500
Lease operating expenses	$ 13,500 – $ 15,500	$ 80,000 – $ 82,000
Transportation expenses	$ 9,000 – $ 10,000	$ 63,000 – $ 64,000
Taxes, other than income taxes	$ 3,000 – $ 4,000	$ 14,500 – $ 15,500

Adjusted general and administrative expenses (Non-GAAP) ^{(4), (7)}	$ 8,500 – $ 9,500	$ 33,000 – $ 34,000
General and administrative- severance expenses	$ 3,500 – $ 4,000	$ 6,000 – $ 6,500

Costs per Mcfe (Mid-Point)	$ 1.74	$ 1.81
Lease operating expenses	$ 0.92	$ 0.92
Transportation expenses	$ 0.61	$ 0.72
Taxes, other than income taxes	$ 0.21	$ 0.17

Targets (Mid-Point in thousands)
Adjusted EBITDAX (Non-GAAP)⁽⁷⁾	$ 11,000 ⁽⁵⁾	$ 81,000 ⁽⁶⁾
Capital expenditures	$ 4,000	$ 66,000
VPP Notes interest expense payments	$ 500	$ 2,600
VPP Notes principal payments	$ 1,500	$ 6,800

Weighted Average NYMEX Differentials
Natural gas (MMBtu)	($ 0.40) – ($ 0.20)	($ 0.35) – ($ 0.30)
Oil (Bbl)	($ 2.40) – ($ 1.80)	($ 1.70) – ($ 1.30)
NGL price as a % of crude oil price	24% – 28%	28% – 32%

Unhedged Commodity Price Assumptions	Oct 19	Nov 19	Dec 19	2019E
Natural gas (MMBtu)	$2.43	$2.21	$2.46	$2.59
Oil (Bbl)	$54.70	$54.70	$54.78	$56.47
NGL (Bbl)	$14.52	$14.38	$13.76	$17.03


(1) Includes other revenues and margin on marketing activities for Upstream assets, only
(2) Includes helium revenues from the VPP Interests of approximately $1.8 million
(3) Includes helium revenues from the VPP Interests of approximately $12.8 million
(4) Excludes share-based compensation expenses and severance expenses
(5) Includes severance expenses of approximately $3.7 million
(6) Includes severance expenses of approximately $6.0 million
(7) The Company does not provide a reconciliation of such non-GAAP financial measures to the most directly comparable GAAP financial measures on a forward-looking basis as it is unable to forecast certain items that we have defined as “Selected Items Impacting Comparability”, which items are set forth later in this press release under the heading “Non-GAAP Financial Measures and Selected Items Impacting Comparability,” without unreasonable effort, due to the uncertainty and inherent difficulty of predicting the occurrence and financial impact of and the periods in which such items may be recognized. Thus, a reconciliation of such non-GAAP financial measures to the most directly comparable GAAP financial measures could result in disclosure that could be imprecise or potentially misleading. These items could be material to and have a significant impact on the Company’s results computed in accordance with GAAP.

Hedging Update

Riviera Upstream Hedges
	2019		2020
*Natural Gas*	Volume (MMMBtu/d)	Average Price (per MMBtu)	Volume (MMMBtu/d)	Average Price (per MMBtu)
Swaps	141	$ 2.88	30	$ 2.82
Collars	20	$ 2.75 – $3.00
*Oil*	Volume (Bbls/d)	Average Price (per Bbl)	Volume (Bbls/d)	Average Price (per Bbl)
Swaps	1,000	$ 64.32	500	$ 64.63
*Natural Gas Basis Differential positions*	Volume (MMMBtu/d)	Average Price (per MMBtu)	Volume (MMMBtu/d)	Average Price (per MMBtu)
PEPL Basis Swaps	70	($ 0.64)	20	($ 0.45)
NWPL Basis Swaps	10	($ 0.61)	–	$ –

Blue Mountain Revenue Hedges
	2019		2020
*Natural Gas*	Volume (MMMBtu/d)	Average Price (per MMBtu)	Volume (MMMBtu/d)	Average Price (per MMBtu)
Swaps	15	$ 2.81	–	$ –
*Oil*	Volume (Bbls/d)	Average Price (per Bbl)	Volume (Bbls/d)	Average Price (per Bbl)
Swaps	98	$ 66.60	49	$ 55.90
*Natural Gas Basis Differential positions*	Volume (MMMBtu/d)	Average Price (per MMBtu)	Volume (MMMBtu/d)	Average Price (per MMBtu)
Southern Star Basis Swaps	5	($ 0.57)	–	$ –
Enable Basis Swaps	5	($ 0.23)	–	$ –
*NGL positions*	Volume (gallons/d in thousands)	Average Price (per gallon)	Volume (gallons/d in thousands)	Average Price (per gallon)
Margin spreads
Mont Belvieu propane and Conway propane	63	($ 0.07)	–	$ –
Mont Belvieu pentane and Conway pentane	63	($ 0.09)	–	$ –

Blue Mountain Cost Hedges
	2019		2020
*NGL positions*	Volume (gallons/d in thousands)	Average Price (per gallon)	Volume (gallons/d in thousands)	Average Price (per gallon)
Fixed price swaps
Mont Belvieu ethane	126	$ 0.34	–	$ –
Mont Belvieu propane	42	$ 0.68	–	$ –

Earnings Call / Form 10‑Q
The Company will host a conference call Thursday, November 7, 2019 at 10:00 a.m. (Central) to discuss the Company’s third quarter 2019 results and expects to file its third quarter Form 10-Q with the Securities and Exchange Commission on or around that date. There will be prepared remarks by executive management followed by a question and answer session.

Investors and analysts are invited to participate in the call by dialing (866) 416-7462, or (409) 217-8223 for international calls using Conference ID: 6994895. Interested parties may also listen over the internet at www.rivieraresourcesinc.com. A replay of the call will be available on the Company’s website.

Supplemental information can be found at the following link on our website: http://ir.rivieraresourcesinc.com/events-and-presentations

ABOUT RIVIERA RESOURCES
Riviera Resources, Inc. is an independent oil and natural gas company with a strategic focus on efficiently operating its mature low-decline assets, developing its growth-oriented assets, and returning capital to its stockholders. Riviera’s properties are located in East Texas, North Louisiana, the Uinta Basin and Mid-Continent regions. Riviera also owns Blue Mountain Midstream LLC, a midstream company centered in the core of the Merge play in the Anadarko Basin.

Non-GAAP Financial Measures and Selected Items Impacting Comparability
To supplement our financial information presented in accordance with GAAP, management uses additional measures known as “non-GAAP financial measures” in its evaluation of past performance and prospects for the future. The primary additional measures used by management are earnings before interest, taxes, depreciation and amortization, exploration costs, noncash gains and losses on commodity derivatives, accrued settlements on commodity derivative contracts related to current production period, share-based compensation expenses, gains and losses on asset sales and other, reorganization items, and asset impairments (“Adjusted EBITDAX”) and earnings before interest, taxes, depreciation and amortization, noncash gains and losses on commodity derivatives, accrued settlements on commodity derivative contracts related to current production period, share-based compensation expenses, gains and losses on asset sales and other, and asset impairments (“Adjusted EBITDA”). Management believes these non-GAAP financial measures provide useful information to investors because these non-GAAP measures, when viewed with the Company’s GAAP results and accompanying reconciliations, provide a more complete understanding of the Company’s performance than GAAP results alone.

Forward-Looking Statements
Statements made in this press release that are not historical facts are “forward-looking statements.” These statements are based on certain assumptions and expectations made by the Company which reflect management’s experience, estimates and perception of historical trends, current conditions, and anticipated future developments. These statements include, among others, statements regarding our 2019 guidance, planned capital expenditures, increases in oil and gas production, the number of anticipated wells to be drilled or completed after the date hereof, future cash flows and borrowings, our strategic objectives with respect to Blue Mountain Midstream, our financial position, business strategy and other plans and objectives for future operations. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the Company, which may cause actual results to differ materially from those implied or anticipated in the forward-looking statements. These include risks relating to the Company’s financial and operational performance and results, low or declining commodity prices and demand for oil, natural gas and natural gas liquids, ability to hedge future production, ability to replace reserves and efficiently develop current reserves, the capacity and utilization of midstream facilities and the regulatory environment. These and other important factors could cause actual results to differ materially from those anticipated or implied in the forward-looking statements. Please read “Risk Factors” in the Company’s Annual Report on Form 10-K, Quarterly Reports on Form 10-Q and other public filings. The Company undertakes no obligation to publicly update any forward-looking statements, whether as a result of new information or future events.

CONTACT:
Investor Relations
(281) 840-4168
[email protected]


CONDENSED CONSOLIDATED BALANCE SHEETS
(Unaudited)

	September 30, 2019			December 31, 2018
	(in thousands, except share amounts)
ASSETS
Current assets:
Cash and cash equivalents	$	83,161		$	18,529
Accounts receivable – trade, net		67,156			114,489
Derivative instruments		14,132			10,758
Restricted cash		45,757			31,248
Other current assets		12,699			26,721
Assets held for sale		419,290			38,396
Total current assets		642,195			240,141
Noncurrent assets:
Oil and natural gas properties (successful efforts method)		316,973			756,552
Less accumulated depletion and amortization		(64,796	)		(93,507	)
		252,177			663,045

Other property and equipment		461,847			606,244
Less accumulated depreciation		(54,991	)		(62,368	)
		406,856			543,876

Derivative instruments		1,243			4,603
Deferred income taxes		—			129,091
Other noncurrent assets		9,376			12,078
		10,619			145,772
Total noncurrent assets		669,652			1,352,693
Total assets	$	1,311,847		$	1,592,834
LIABILITIES AND EQUITY
Current liabilities:
Accounts payable and accrued expenses	$	104,726		$	159,228
Derivative instruments		4,087			4,719
Other accrued liabilities		48,122			34,474
Liabilities held for sale		127,023			3,725
Total current liabilities		283,958			202,146
Noncurrent liabilities:
Credit facilities		61,100			24,500
Asset retirement obligations		52,143			103,814
Other noncurrent liabilities		13,210			—
Total noncurrent liabilities		126,453			128,314
Commitments and contingencies (Note 10)
Equity:
Preferred Stock ($0.01 par value, 30,000,000 shares authorized; no shares issued at September 30, 2019, or December 31, 2018)		—			—
Common Stock ($0.01 par value, 270,000,000 shares authorized; 58,632,328 shares and 69,197,284 shares issued at September 30, 2019, and December 31, 2018, respectively)		586			692
Additional paid-in capital		1,115,483			1,256,730
Retained earnings		(214,633	)		4,952
Total equity		901,436			1,262,374
Total liabilities and equity	$	1,311,847		$	1,592,834

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
	(in thousands, except per share amounts)
Revenues and other:
Oil, natural gas and natural gas liquids sales	$	51,029		$	89,653		$	194,131		$	313,533
Gains (losses) on commodity derivatives		5,665			(3,175	)		12,673			(25,730	)
Marketing revenues		45,828			67,246			166,569			156,480
Other revenues		5,532			5,877			16,685			18,158
		108,054			159,601			390,058			462,441
Expenses:
Lease operating expenses		18,307			22,930			66,204			94,902
Transportation expenses		16,275			22,304			53,478			62,611
Marketing expenses		37,688			63,149			132,888			145,231
General and administrative expenses		16,954			90,931			49,434			228,105
Exploration costs		1,947			2,487			4,154			3,742
Depreciation, depletion and amortization		20,060			21,515			65,013			71,960
Impairment of assets held for sale		95,080			—			113,470			—
Taxes, other than income taxes		5,111			7,162			14,010			22,729
(Gains) losses on sale of assets and other, net		(7,587	)		221			(24,967	)		(208,009	)
		203,835			230,699			473,684			421,271
Other income and (expenses):
Interest expense, net of amounts capitalized		(2,329	)		(594	)		(5,403	)		(1,582	)
Other, net		(595	)		105			(708	)		473
		(2,924	)		(489	)		(6,111	)		(1,109	)
Reorganization items, net		(284	)		(1,277	)		(756	)		(4,487	)
(Loss) income from continuing operations before income taxes		(98,989	)		(72,864	)		(90,493	)		35,574
Income tax expense (benefit)		126,646			(39,628	)		129,092			25,247
(Loss) income from continuing operations		(225,635	)		(33,236	)		(219,585	)		10,327
(Loss) income from discontinued operations, net of income taxes		—			(14,899	)		—			19,674
Net (loss) income	$	(225,635	)	$	(48,135	)	$	(219,585	)	$	30,001
Income (loss) per share:
(Loss) income from continuing operations per share ‒ Basic	$	(3.76	)	$	(0.43	)	$	(3.40	)	$	0.13
(Loss) income from continuing operations per share ‒ Diluted	$	(3.76	)	$	(0.43	)	$	(3.40	)	$	0.13

(Loss) income from discontinued operations per share ‒ Basic	$	—		$	(0.20	)	$	—		$	0.26
(Loss) income from discontinued operations per share ‒ Diluted	$	—		$	(0.20	)	$	—		$	0.26

Net (loss) income per share ‒ Basic	$	(3.76	)	$	(0.63	)	$	(3.40	)	$	0.39
Net (loss) income per share ‒ Diluted	$	(3.76	)	$	(0.63	)	$	(3.40	)	$	0.39

Weighted average shares outstanding ‒ Basic		60,004			76,135			64,576			76,171
Weighted average shares outstanding ‒ Diluted		60,004			76,135			64,576			76,518

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

	Nine Months Ended September 30,
	2019			2018
	(in thousands)
Cash flow from operating activities:
Net (loss) income	$	(219,585	)	$	30,001
Adjustments to reconcile net (loss) income to net cash provided by (used in) operating activities:
Income from discontinued operations		—			(19,674	)
Depreciation, depletion and amortization		65,013			71,960
Impairment of assets held for sale		113,470			—
Deferred income taxes		129,092			25,382
Total (gains) losses on derivatives, net		(6,386	)		25,730
Cash settlements on derivatives		5,740			(25,341	)
Share-based compensation expenses		10,624			16,105
Gains on sale of assets and other, net		(27,366	)		(204,644	)
Other		8,897			1,336
Changes in assets and liabilities:
Decrease in accounts receivable – trade, net		37,305			57,674
Decrease in other assets		5,367			61,309
Decrease in accounts payable and accrued expenses		(29,997	)		(51,608	)
Decrease in other liabilities		(4,331	)		(15,750	)
Net cash provided by (used in) operating activities		87,843			(27,520	)
Cash flow from investing activities:
Acquisition of property, plant and equipment		(3,380	)		—
Development of oil and natural gas properties		(67,864	)		(56,116	)
Purchases of other property and equipment		(82,232	)		(116,237	)
Proceeds from sale of properties and equipment and other		177,907			367,086
Net cash provided by investing activities — continuing operations		24,431			194,733
Net cash provided by investing activities — discontinued operations		—			7,000
Net cash provided by investing activities		24,431			201,733
Cash flow from financing activities:
Net transfers to Parent		—			(481,449	)
Repurchases of shares		(143,097	)		(7,576	)
Proceeds from borrowings		142,825			—
Repayments of debt		(29,615	)		—
Debt issuance costs paid		(3,246	)		(2,505	)
Distributions to unitholders		—			(18,717	)
Other		—			(841	)
Net cash used in financing activities		(33,133	)		(511,088	)
Net increase (decrease) in cash, cash equivalents and restricted cash		79,141			(336,875	)
Cash, cash equivalents and restricted cash:
Beginning		49,777			520,922
Ending	$	128,918		$	184,047

Adjusted EBITDAX (Non-GAAP Measure)

The non-GAAP financial measure of Adjusted EBITDAX, as defined by the Company, may not be comparable to similarly titled measures used by other companies. Therefore, this non-GAAP measure should be considered in conjunction with net income (loss) and other performance measures prepared in accordance with GAAP. Adjusted EBITDAX should not be considered in isolation or as a substitute for GAAP.

Adjusted EBITDAX is a measure used by Company management to evaluate the Company’s operational performance and for comparisons to the Company’s industry peers. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results.


The following presents a reconciliation of net income (loss) to Adjusted EBITDAX:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2019			2018			2019			2018
	(in thousands)
Net (loss) income	$	(225,635	)	$	(48,135	)	$	(219,585	)	$	30,001
Plus (less):
Loss (income) from discontinued operations		—			14,899			—			(19,674	)
Interest expense, net of amounts capitalized		2,329			594			5,403			1,582
Income tax expense (benefit)		126,646			(39,628	)		129,092			25,247
Depreciation, depletion and amortization		20,060			21,515			65,013			71,960
Exploration costs		1,947			2,487			4,154			3,742
EBITDAX		(74,653	)		(48,268	)		(15,923	)		112,858
Plus (less):
Noncash losses (gains) on commodity derivatives		3,738			2,869			(478	)		20,360
Accrued settlements on commodity derivative contracts related to current production period ⁽¹⁾		(154	)		(124	)		(1,182	)		1,444
Share-based compensation expenses		2,832			56,063			12,819			131,288
(Gains) losses on sale of assets and other, net ⁽²⁾		(6,444	)		23			(25,230	)		(207,237	)
Reorganization items, net ⁽³⁾		284			1,277			756			4,487
Impairment of assets held for sale		95,080			—			113,470			—
Adjusted EBITDAX ⁽⁴⁾	$	20,683		$	11,840		$	84,232		$	63,200

⁽¹⁾ Represent amounts related to commodity derivative contracts that settled during the respective period (contract terms had expired) but cash had not been received as of the end of the period.
⁽²⁾ Primarily represent gains or losses on the sale of assets, earnings from equity method investments, gains or losses on inventory valuation, and write-off of deferred financing fees.
⁽³⁾ Represent costs and income directly associated with the predecessor’s filing for voluntary reorganization under Chapter 11 of the U.S. Bankruptcy Code since the petition date, and also include adjustments to reflect the carrying value of certain liabilities subject to compromise at their estimated allowed claim amounts, as such adjustments were determined.
⁽⁴⁾ Includes success fee on capital reimbursement agreement of approximately $2 million for both the three months and nine months ended September 30, 2019.

Adjusted EBITDAX and Adjusted EBITDA (Non-GAAP Measures)

The non-GAAP financial measures of Adjusted EBITDAX and adjusted EBITDA, as defined by the Company, may not be comparable to similarly titled measures used by other companies. Therefore, these non-GAAP measures should be considered in conjunction with net income (loss) and other performance measures prepared in accordance with GAAP. Adjusted EBITDAX and Adjusted EBITDA should not be considered in isolation or as a substitute for GAAP.

Adjusted EBITDAX and Adjusted EBITDA are measures used by Company management to evaluate the Company’s operational performance and for comparisons to the Company’s industry peers. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results.


The following presents a reconciliation of net income (loss) to Adjusted EBITDAX and Adjusted EBITDA:

		Three Months Ended September 30, 2019
		(in thousands)
		Consolidated		Upstream			Blue Mountain

Net loss	$	(225,635	)	$	(222,365	)	$	(3,270	)
Plus (less):
Interest expense		2,329			1,711			618
Income tax expense		126,646			126,646			—
Depreciation, depletion and amortization		20,060			17,593			2,467
EBITDA		(76,600	)		(76,415	)		(185	)
Exploration costs		1,947			1,947			—
EBITDAX		(74,653	)		(74,468	)		(185	)
Plus (less):
Noncash losses (gains) on commodity derivatives		3,738			4,629			(891	)
Accrued settlements on commodity derivative contracts related to current production period ⁽¹⁾		(154	)		(68	)		(86	)
Share-based compensation expenses		2,832			623			2,209
(Gains) losses on sale of assets and other, net ⁽²⁾		(6,444	)		(6,616	)		172
Reorganization items, net ⁽³⁾		284			284			—
Impairment of assets held for sale		95,080			95,080			—
Adjusted EBITDAX / Adjusted EBITDA ⁽⁴⁾	$	20,683		$	19,464		$	1,219

		Nine Months Ended September 30, 2019
		(in thousands)
		Consolidated		Upstream			Blue Mountain

Net loss	$	(219,585	)	$	(213,878	)	$	(5,707	)
Plus (less):
Interest expense		5,403			4,170			1,233
Income tax expense		129,092			129,092			—
Depreciation, depletion and amortization		65,013			58,122			6,891
EBITDA		(20,077	)		(22,494	)		2,417
Exploration costs		4,154			4,154			—
EBITDAX		(15,923	)		(18,340	)		2,417
Plus (less):
Noncash (gains) losses on commodity derivatives		(478	)		(4,036	)		3,558
Accrued settlements on commodity derivative contracts related to current production period ⁽¹⁾		(1,182	)		(17	)		(1,165	)
Share-based compensation expenses		12,819			4,623			8,196
(Gains) losses on sale of assets and other, net ⁽²⁾		(25,230	)		(26,211	)		981
Reorganization items, net ⁽³⁾		756			756			—
Impairment of assets held for sale		113,470			113,470			—
Adjusted EBITDAX / Adjusted EBITDA ⁽⁴⁾	$	84,232			70,245		$	13,987

⁽¹⁾ Represent amounts related to commodity derivative contracts that settled during the respective period (contract terms had expired) but cash had not been received as of the end of the period.
⁽²⁾ Primarily represent gains or losses on the sale of assets, earnings from equity method investments, gains or losses on inventory valuation, and write-off of deferred financing fees.
⁽³⁾ Represent costs and income directly associated with the predecessor’s filing for voluntary reorganization under Chapter 11 of the U.S. Bankruptcy Code since the petition date, and also include adjustments to reflect the carrying value of certain liabilities subject to compromise at their estimated allowed claim amounts, as such adjustments were determined.
⁽⁴⁾ Consolidated and Blue Mountain include success fee on capital reimbursement agreement of approximately $2 million for both the three months and nine months ended September 30, 2019.